Continuous Storage Facility ParticipationPart of the Enhanced Storage Participation Revisions and...

ISO-NE PUBLIC

Disclaimer for Customer Training: ISO New England (ISO) provides training to enhance participant and stakeholder understanding. Not all issues and requirements are addressed by the training. Consult the effective Transmission, Markets and Services Tariff and the relevant Market Manuals, Operating Procedures and Planning Procedures for detailed information. In case of a discrepancy between training provided by ISO and the Tariff or Procedures, the meaning of the Tariff and Procedures shall govern.

ISO-NE PUBLIC

Part of the Enhanced Storage Participation Revisions and Energy Storage Device Project

February 21, 2019

WebEx Broadcast

Manager, Customer Support

Tim Peet

Lead Analyst, Asset Registration & New Generation CoordinationJacques Asselin

Continuous Storage Facility Participation

Sr. Settlement Analyst, Hourly Markets, SettlementsSarthak Pant

Note this presentation was updated on 2/27/2019. Impacted slide is 47.

http://www.iso-ne.com/regulatory/tariff/index.html

http://www.iso-ne.com/rules_proceds/isone_mnls/index.html

http://www.iso-ne.com/rules_proceds/operating/index.html

http://www.iso-ne.com/rules_proceds/isone_plan/index.html

ISO-NE PUBLIC

Disclaimer for Customer TrainingISO New England (ISO) provides training to enhance participant and stakeholder understanding. Because not all issues and requirements are addressed by the training, participants and other stakeholders should not rely solely on this training for information but should consult the effective Transmission, Markets and Services Tariff (“Tariff”) and the relevant Market Manuals, Operating Procedures and Planning Procedures (“Procedures”).

Training examples are provided for illustrative purposes only. Company names and numerical values used are fictitious.

In case of a discrepancy between training provided by ISO and the Tariff or Procedures, the meaning of the Tariff and Procedures shall govern.

Presentation assumes approval of Enhanced Storage Participation Revisions (ER19–84–000).

2

http://www.iso-ne.com/regulatory/tariff/index.html

http://www.iso-ne.com/rules_proceds/isone_mnls/index.html

http://www.iso-ne.com/rules_proceds/operating/index.html

http://www.iso-ne.com/rules_proceds/isone_plan/index.html

https://www.iso-ne.com/static-assets/documents/2018/10/er19-84-000_enhanced_storage_revisions.pdf

ISO-NE PUBLIC

Topics

1. Continuous Storage Facility (CSF) Option

2. Market Participation by Continuous Storage Facilities

3. Initial Modeling, Technical Requirements, and

Asset Registration

4. eMarket Requirements

5. Examples of How a CSF May Offer or Bid into Markets

6. Settlements and Billing Impacts

3

ISO-NE PUBLIC

Objectives

• Identify continuous storage facility option

• Describe how to register as continuous storage facility

• Recall requirements for managing CSF assets in

eMarket software platform

• Discuss examples of how CSF may offer or bid in to markets

• Recognize CSF settlement changes

• Locate helpful information, including alternative options that storage

facilities have for market participation

4

ISO-NE PUBLIC

Customer Readiness: Energy Storage Device ProjectSystems Project to Accommodate Enhanced Storage Participation Revisions

• Target launch: April 1, 2019

• Action items and resources

available on ISO website

• See Customer Readiness sectionEnergy Storage Device (ESD) Project

5

https://www.iso-ne.com/participate/support/customer-readiness-outlook/esd-project

ISO-NE PUBLIC

Topics NOT Covered Today

• Other participation options for storage facilities

‒ See Energy Storage Market Participation Overview recording and

presentation at Participate > Training > Training Materials

• Operator training

‒ Search ISO Training & Events Network (ISO-TEN) for training on

operating equipment and communicating with ISO control room

‒ For specifics on remote terminal units (RTUs), see Operating

Procedure #14, Technical Requirements For Generators, Demand

Response Resources, Asset Related Demands, and Alternative

Technology Regulation Resources (OP14)

• Additional actions to complete compliance

‒ Follow developments on NEPOOL Markets Committee webpage

regarding FERC Order No. 841 Final Rule on Electric Storage

Participation in Regional Markets

6

https://www.iso-ne.com/static-assets/documents/2017/04/20170411-webinar-energy-storage.htm

https://www.iso-ne.com/static-assets/documents/2017/04/20170411-webinar-energy-storage.pdf

https://isone.csod.com/

https://www.iso-ne.com/participate/rules-procedures/operating-procedures/

https://www.iso-ne.com/committees/markets/markets-committee/?open_projects_value=Order No. 841 Compliance - WMPP ID: 129

https://www.ferc.gov/whats-new/comm-meet/2018/021518/E-1.pdf?csrt=8502462807159516542

ISO-NE PUBLIC

AGC automatic generation control MR1 Market Rule 1 (Section III of ISO Tariff)

ARD asset-related demand MW megawatt

ATRR alternative technology regulation resource MWh Megawatt-hour

CLAIM10 offline 10-minute nonspinning reserves MyFacility_ARD CSF’s DARD

CLAIM30 offline 30-minute operating reserve MyFacility_ATRR CSF’s ATRR

CROW Control Room Operations Window (interface) MyFacility_GEN CSF’s generator asset

CSF continuous storage facility NCPC net commitment-period compensation

DAM Day-Ahead Energy Market NEPOOL New England Power Pool

DARD dispatchable asset-related demand NPCC Northeast Power Coordinating Council

DDP desired dispatch point OP operating procedure

DE designated entity PTF pool transmission facility

Eco Max economic maximum value PURPA Public Utility Regulatory Policies Act

Eco Min economic minimum value Reg High regulation high value

ESD energy storage device Reg Low regulation low value

FCM Forward Capacity Market RQM revenue quality meter

FCTS Forward Capacity Tracking System RTM Real-Time Energy Market

FERC Federal Energy Regulatory Commission RTU remote terminal unit

ISO-TEN ISO Training & Events Network SOG settlement-only generator

LEG limited-energy generator TMNSR 10-minute nonspinning reserves

LMP locational marginal price; lead market participant TMOR 30-minute operating reserves

MIS market information server TMSR 10-minute spinning reserves

Acronyms

7

ISO-NE PUBLIC

Market Rule References

• Rules specific to continuous storage facilities are in Section III of ISO New England Inc.

Transmission, Markets, and Services Tariff

‒ Section III known as Market Rule 1 (MR1)

‒ See Section III.1.10.6, Electric Storage

• Available now in FERC filing

• Available in published Market Rule 1 on April 1, 2019

• For non-CSF market participation, see market-specific rules applying to all technologies

• CSFs also subject to ISO‐NE Operating Procedures:

‒ No. 14 (OP 14): Technical Requirements For Generators, Demand Resources, Asset Related Demands,

and Alternative Technology Regulation Resources

‒ No. 18 (OP 18): Metering and Telemetering Criteria

MR1, Section III.1.10.6

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Look for tariff references at bottom left


https://www.iso-ne.com/participate/rules-procedures/tariff/market-rule-1


ISO-NE PUBLICISO-NE PUBLIC

Continuous Storage Facility Option

9


Tim Peet

ISO-NE PUBLIC

A Long and Evolving History

• Since 1970s, 2,000 MW pumped-storage hydro active

in New England

‒ Have provided energy, reserves, regulation, and capacity since

inception of region’s wholesale electricity markets

• Early 2016, interest began growing in building new

storage technologies

‒ Hundreds of MWs of battery storage currently in

ISO New England Interconnection Request Queue

10

ISO-NE PUBLIC

Pumped-Storage Hydro Operates in Binary Fashion

• Reversible pump/turbine:

‒ Spins in one direction to pump water uphill

(aka, charging)

‒ Stops and takes time to spin in reverse to

generate electricity (aka, discharging)

• Has two corresponding asset types

modeled in ISO system and participating

in markets:

‒ Charging: Dispatchable asset-related demand

(DARD) submits bids to consume energy

‒ Discharging: Generator asset offers to supply

energy and provide regulation

11

OR

ISO-NE PUBLIC

New Storage Technologies Operate in Continuous Fashion

Batteries and similar technologies can:

• Move continuously and nearly instantaneously

between charging and discharging in continuous

range of generation and consumption

• Set regulation range that crosses zero and

can provide regulation while charging

or discharging

12

ISO-NE PUBLIC

Expanding Options for Storage in New England

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March 2015—Regulation Market Redesign April 1, 2019—Enhanced Storage Participation Revisions

New energy-neutral regulation dispatch signal for storage participating as alternative technology regulation resources (ATRRs)

(aka, Energy Storage Device Project)• Introduces electric storage facility rules for:

– Binary storage facilities (i.e., pumped-storage hydro)– Continuous storage facilities (e.g., batteries)

• Storage facilities as small as 1 MW can participate

June 2018—Price-Responsive Demand Project December 2019—Additional revisions include:

Enabled demand response to participate in energy market as dispatchable resource and provide reserves

• Any technology can participate under binary storage facility rules

• Electric storage facilities as small as 0.1 MW can participate

• Electric storage facilities may be exempted from Schedule 9 (regional network service) charges when consuming


ISO-NE PUBLIC

What Are Electric Storage Facilities?

In New England markets, this means storage facilities that:

• Are capable of receiving electricity from the grid and storing

the energy for later injection of electricity back to the grid

• Register as and follow rules for both:

‒ Dispatchable generator asset

‒ Dispatchable asset-related demand (DARD)

• Qualify as one of two subtypes:

‒ Binary storage facility (i.e., pumped storage)

‒ Continuous storage facility (e.g., batteries)

• Can simultaneously participate in energy,

reserves, and regulation markets


14

ISO-NE PUBLIC

Qualifying as a Continuous Storage Facility (CSF)

In addition to general electric storage facility

requirements, CSFs must be capable of max

output to max consumption in ≤10 minutes


15

ISO-NE PUBLIC

Qualifying as a Continuous Storage Facility (CSF), continued

CSFs must also register as ATRR:

• Must all be same equipment

• Can’t use storage capability shared with another

generator asset, DARD, or ATRR

• Not required to actually provide regulation


16

Participation as a continuous storage facility is optional, except for:

• ATRRs ≥5 MW

• Facilities of any size registered with this three-part configuration

!

ISO-NE PUBLICISO-NE PUBLICISO-NE PUBLIC

Questions?

17

Coming Up: Market Participation by Continuous Storage Facilities Initial Modeling, Technical Requirements, and Asset Registration eMarket Requirements Examples Settlement and Billing Impacts Additional Resources


Market Participation by Continuous Storage Facilities

18

ISO-NE PUBLIC

New England’s Wholesale Electricity Market

19

WholesaleElectricity

Market

EnergyMarket

Produces financially binding schedules for production and consumption of electricity day before operating day

Day-Ahead Energy Market

Balances differences between day-ahead scheduled amounts of electricity and actual real-time requirements

Real-Time Energy Market

System for purchasing and selling electricity using supply and demand to set price

Ancillary Services Market

Services that ensure reliability of production and transmission of electricity

Forward Capacity Market

Forward market where resources are compensated for delivery of capacity in three years’ time

Resources available to respond within 10- and 30-minutes to meet demand under certain contingencies; includes Forward Reserve and Real-Time Reserve Markets

Reserve

Provide reactive power for voltage control and supportVoltage Support

Resources increase or decrease output every four seconds in response to signals from ISO to balance supply levels with second-to-second variations in demand

Regulation

Support restoration of power system after partial or complete shutdown of system

Blackstart

ISO-NE PUBLIC

Different Asset Types Correspond to Different Abilities and Markets

• A CSF’s three asset types enable simultaneous

participation in energy, reserves, and regulation markets

• Each asset responsible for different operating activity


20

Generator Asset DARD ATRR

Used to inject energy into grid and

provide reserves

Used to manage energy consumed

and reserves

Used to manage regulation (positive

or negative)

CSFs cannot participate as demand response; must be directly metered, with no load behind same meter

ISO-NE PUBLIC

Day-Ahead Energy Market

• CSF’s generator and DARD assets may participate

‒ CSF’s generator asset required to offer in if they have

capacity supply obligation through Forward Capacity Market

• Both generator asset and DARD always committed

online at 0 MW, unless participant declares it

unavailable in eMarket

‒ Each CSF asset must be online and operational unless

declared unavailable

21

ISO-NE PUBLIC

Day-Ahead Energy Market, continued

• Dispatch level based on offers and

economics, with each asset receiving:

‒ Independent dispatch MW level when cleared

‒ Zero when not cleared

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Participant is responsible for developing day-ahead bids and offers so that CSF does not get day-ahead obligation to charge and discharge at same time. ISO day-ahead software will not check this for you.

!

ISO-NE PUBLIC

Real-Time Energy Market

• Assets must self-schedule and be operational

and online, unless declared unavailable

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CSFs must telemeter key inputs to ISO via remote terminal unit (RTU), including available MWhs of energy and available MWhs of storage.

See RTU and telemetry requirements in ISO‐NE Operating Procedures No. 18 (OP 18): Metering and Telemetering Criteria.

!


ISO-NE PUBLIC

Real-Time Energy Market, continued

• CSF assets dispatched based on charge status:

‒ When fully discharged (i.e., available energy = 0 MWh)

only DARD is available for dispatch

‒ When fully charged (i.e., available storage = 0 MWh)

only generator asset is available for dispatch

‒ When partially charged or discharged, dispatch based

on offer parameters, availability status, and dispatch

limits economically

• Dispatch limits updated based on telemetered

available energy and storage

24

ISO-NE PUBLIC

Reserve Markets

• CSF can provide 10-minute spinning reserves

with generator asset and DARD, not ATRR

‒ Generator asset: reserves counted from current MW

to economic max parameter

• Economic max may be recalculated by system to meet

reliability requirements based on telemetered output

(details on later slide)

• Participant required to bid Eco Min at 0 MW

‒ DARD asset: reserves counted from current MW to

Minimum Consumption parameter

• Based on absolute value of telemetered output

• Participant required to bid Min Consumption at 0 MW

25

ISO-NE PUBLIC

Reserve Markets, continued

• CSFs do not provide:

‒ Offline 10-minute nonspinning reserves

(aka, CLAIM10)

‒ Offline 30-minute operating reserve

(aka, CLAIM30)

• This is due to requirement to always

be operational and on line, unless

declared unavailable

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ISO-NE PUBLIC

Regulation Market

• CSF’s ATRR asset can participate in

Regulation Market in real time

• Average net energy consumption for ATRR

generally around 0 MWh because:

‒ ATRR regulates via an energy neutral signal

‒ Regulation limits must be set close to symmetric

limits around 0 MW

• Can include small bias towards charging to account

for efficiency loss

27

ISO-NE PUBLIC

Simultaneous Dispatch of CSF

• Dispatch software treats CSF as three

different assets, and calculates separate

dispatch signal for each

• CSF gets single dispatch signal equal to:

‒ Desired dispatch point of generator asset

• Generating output level to which they are

expected to move

‒ Minus desired dispatch point of DARD

• Amount to reduce consumption from

adjusted baseline

‒ Plus AGC setpoint of ATRR

• Signal sent at 4 second intervals


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ISO-NE PUBLIC

Example of Simultaneous Dispatch

29

Gen

DARD

10 MW

−10 MW

ATRR

4 MW

−4 MW

6 MW Energy

6 MW Energy

8 MW Regulation

-10

-5

0

5

10

Regulation Signal Generator DDP DARD DDP

-10

-5

0

5

10

EcoMax Max Consump Reg High Reg Low Dispatch Signal

Single Dispatch

Signal

Individual Dispatch


Questions?

30

Coming Up: Initial Modeling, Technical Requirements, and Asset Registration eMarket Requirements Examples Settlement and Billing Impacts Additional Resources


Initial Modeling, Technical Requirements, and Asset RegistrationMarket Integration Process

31

Lead Analyst, Asset Registration & New Generation Coordination

Jacques Asselin

ISO-NE PUBLIC

Market Integration Process

• Once interconnection is complete, initial modeling,

technical requirements, and registration can take place

• Similar process for projects regardless of technology type

32

InterconnectionProject Kickoff

Meeting

Assign Market

Participant Roles

Assign Designated

Entity

Submit Technical

Documents

Add toPower System Model

Register Asset

Market Integration Process

ISO-NE PUBLIC

The Interconnection Process

Before pursuing market participation, you must complete or be near completion

of the interconnection process

‒ If required to follow ISO New England interconnection process, you must have at least:

• Interconnection Study (System Impact Study) completed

• Proposed Plan Application submitted

‒ Some facilities must follow state interconnection process, instead

33

Per FERC Order No. 2003-A, “Facilities subject to the [open access transmission tariff] are: transmission facilities used to transmit electric energy in interstate commerce either at wholesale or for unbundled retail sales; and ‘distribution’ facilities that are used for wholesale sales in interstate commerce.”

https://www.ferc.gov/legal/maj-ord-reg/land-docs/order2003.asp

ISO-NE PUBLIC

ISO New England vs. State Interconnection Process Overview

1. Is project interconnecting to ISO-administered transmission system

(pool transmission facility [PTF], non-PTF, and FERC-jurisdictional distribution)?

‒ If YES, see #2

‒ If NO, use state interconnection process

• Contact distribution company/owner of state-jurisdictional distribution facility

2. Is project exempt?

‒ If YES, use state interconnection process

‒ If NO, use ISO interconnection process

• See ISO’s New or Modified Interconnections webpage

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For details, see Distribution-Connected Generation Guidance presentation

Exemptions:• Retail customer interconnecting new generating facility whose energy will ONLY be consumed at retail customer’s site• New generating facility connected to distribution facility subject to ISO Tariff, IF generating facility will not be used to make

wholesale sales of electricity in interstate commerce• Qualifying facility defined by PURPA, where facility’s owner intends to sell all output to its interconnected electric utility

https://www.iso-ne.com/participate/applications-status-changes/new-modified-interconnections/

https://www.iso-ne.com/static-assets/documents/2017/07/a5_distributed_connected_generation_guidance.pdf

ISO-NE PUBLIC

• Should be scheduled 12–15 months in

advance of targeted commercial

operation date

‒ Contact ISO via Ask ISO or

[email protected]

• Meeting will review action items for

market integration

‒ Process outlined in New Generation Projects:

Process Guide

Market Integration: Project Kickoff Meeting

35

Project Kickoff

Meeting

Assign Market

Participant Roles

Assign Designated

Entity

Submit Technical

Documents


Register Asset

https://askiso.force.com/

mailto:[email protected]

https://www.iso-ne.com/static-assets/documents/2016/08/new_generator_projects_process_guide.pdf

ISO-NE PUBLIC

• Specify which market participants will play

required roles related to CSFs

‒ Can be same or different market participants

• Each role has different responsibilities for:

‒ Scheduling and bidding assets to market

‒ Wholesale settlement obligation (regulation,

energy, reserves)

‒ Forward Capacity Market

Market Integration: Assign Market Participant Roles

36

Project Kickoff

Meeting

Assign Market

Participant Roles

Assign Designated

Entity

Submit Technical

Documents

Add to Power System Model

Register Asset

ISO-NE PUBLIC

Market Participant Roles and Responsibilities for CSFs

37

Roles can be filled by same or different market

participants

GEN DARDATRR

ASSET Lead Market Participant

Capacity Product

Continuous Storage Facility

Owner(s)

Designated Entity

RESOURCE Lead Market Participant

eMarket

DISPATCH

$SETTLEMENTS RESOURCE Lead

Market Participant

FCTS

Forward Capacity Tracking System

ISO-NE PUBLIC

Market Participant Roles and Responsibilities for CSFs, continued

• Asset lead market participant

‒ Single settleable market participant

‒ Acts as “quarterback” for CSF

‒ Responsible for:

• Technical documentation and market compliance

• Day-to-day offers and bidding of CSF assets in eMarket for

energy (injections and withdrawals), reserves, and regulation

• Asset owner(s)

‒ Incurs settlement obligation for:

• Generator asset (energy injections)

• ATRR (regulation)

• DARD (energy withdrawals)

• Designated entity

‒ Handles dispatch communications

38

eMarket

DISPATCH

$SETTLEMENTS

Roles can be filled by same or different market

participants

ISO-NE PUBLIC

Market Participant Roles and Responsibilities for CSFs, continued

• Resource lead market participant:

‒ Single entity

‒ May be one of the market participants associated with asset

OR another market participant

‒ Responsible for capacity market-related

• Administrative functions

• Offers

• Settlement

• More information on capacity market:

‒ FCM Participation Guide

• New Capacity Qualification for Energy Storage Resources

Webinar recording and presentation

39

Capacity Product

https://www.iso-ne.com/markets-operations/markets/forward-capacity-market/fcm-participation-guide

https://www.iso-ne.com/static-assets/documents/2019/02/redirect_cms-fcm-new-capacity-qualification-energy-storage.htm

https://www.iso-ne.com/static-assets/documents/2019/02/fcm-new-capacity-qualification-energy-storage.pdf

ISO-NE PUBLIC

• Designated entity is responsible for 24/7 dispatch

communications with ISO control room

‒ Must have equipment dedicated to ISO New England

‒ If not, allow 90 days to order/deliver/install:

• Remote terminal unit (RTU)

• Electronic dispatch circuits/router

• Exclusive phone line

• ISO validates assigned dispatch

location and coordinates

registration, if needed

Market Integration: Assign Designated Entity (DE)

40

Project Kickoff

Meeting

Assign Market

Participant Roles

Assign Desig-nated Entity

Submit Technical

Documents


Register Asset

ISO-NE PUBLIC

• No. 12 (OP 12): Voltage and Reactive Control

• No. 14 (OP 14): Technical Requirements For Generators, Demand Resources,

Asset Related Demands, and Alternative Technology Regulation Resources

‒ Required NX technical data forms available on operating procedures webpage

‒ Separate technical data form required for each asset (generator asset,

ATRR, and DARD)

• No. 16 (OP 16): Transmission

System Data (if necessary)

• No. 18 (OP 18): Metering and

Telemetering Criteria

Market Integration: Submit Technical Documents

41

Project Kickoff

Meeting

Assign Market

Participant Roles

Assign Designated

Entity

Submit Technical

Docu-ments


Register Asset

See requirements in ISO‐NE operating procedures (OPs):



ISO-NE PUBLIC

Market Integration: Add to Power System Model

• Before operating, facility must be represented in ISO New England power system model

• Requires submission of one-line diagram of facility in advance of scheduled model update

(February, May, September)

42

Deadlines for One-Line Diagram Submission

Submit by previous:

For inclusionin update of:

November February

March May

July September

Project Kickoff

Meeting

Assign Market

Participant Roles

Assign Designated

Entity

Submit Technical

Documents


Register Asset

ISO-NE PUBLIC

1. Submit request for continuous

storage registration to Customer

Support via Ask ISO

• See Ask ISO user guide

2. ISO will contact you and guide you

through submitting registration form

‒ Single registration form for all three assets

Market Integration: Register Asset

43

Project Kickoff

Meeting

Assign Market

Participant Roles

Assign Designated

Entity

Submit Technical

Documents


Register Asset


https://www.iso-ne.com/static-assets/documents/support/user_guides/ask_iso_user_guide_external.pdf

ISO-NE PUBLIC

Registration Results in Three Separate Assets IDs

44

MyFacility_GEN

MyFacility_ARD

MyFacility_ATRR

MyFacility

Lead market participant provides facility name; must be unique and ≤26 characters1

Suffixes automatically added to facility name to represent each CSF asset: “_GEN” for generator asset; “_ARD” for DARD; and “_ATRR” for ATRR

2

Asset IDs are generated by ISO and reflected in eMarket3


Questions?

45

Coming Up: eMarket Requirements Examples Settlement and Billing Impacts Additional Resources


eMarket RequirementsRules for Managing Assets, Bids, and Offers

46


Tim Peet

ISO-NE PUBLIC

CSFs Must Follow Certain Rules in eMarket

• Rules for managing availability, bids, and offers

‒ Rules relate to CSF registration and operating characteristics

• Subsequent slides cover only CSF changes,

not general eMarket usage

‒ To learn more about eMarket, see eMarket User Guide and

FAQs: Using eMarket

• Web services and upload/download protocols:

‒ For CSF asset types, same validation rules applied in XML

uploads/downloads as in eMarket user interface

‒ For more information, see Energy Storage Device (ESD)

Project customer readiness webpage

47

There are no changes for non-CSF resources!

eMarket

Slide updated on 2/27/2019.

https://www.iso-ne.com/participate/support/user-guides/

https://www.iso-ne.com/participate/support/faq/emarket


ISO-NE PUBLIC

‒ $0 for:

• Start-up fee

• No-load fee

• To self-schedule and maintain continuous range of potential dispatch points,

CSF assets must specify 0 MW for:

‒ Economic minimum limit (generator asset’s lowest sustainable output level)

‒ Emergency minimum limit (generator asset’s minimum output deliverable for

limited period without exceeding stability limits and operating permits)

‒ Minimum consumption limit (DARD’s lowest available consumption level)

• Since CSF generator asset operates without temporal constraints or costs

and isn’t part of commitment process, it must specify:

‒ 0 value for:

• Notification time

• Start-up time

• Minimum run time

• Minimum down time

Offer and Bid Data Requirements for CSFsValues to be entered into eMarket application


48

eMarket

ISO-NE PUBLIC

Declaring Unavailability or Scheduling OutagesContinuous Storage Facility Must Operate in On-line State Unless Declared Unavailable

Setting Availability Status

• Day ahead: participant sets status in eMarket to Must Run or unavailable

• Real time:

‒ For generator asset and DARD, participant calls ISO control room to change availability

‒ For ATRR, participant can change offer status in eMarket each hour before Regulation Selector is run

• Once ATRR is selected, must call ISO control room to change status

Outages

• CSF generating asset must submit outages into CROW outage scheduler

‒ DARDs and ATRRs cannot schedule outages

49

ISO-NE PUBLIC

How Day-Ahead Asset Status Affects Real-Time Status

• Day-ahead market:‒ Participant can set Must Run or Unavailable status

independently for generator asset and DARD

• ATRR doesn’t participate in Day-Ahead Energy Market

• Real-time operations:‒ For generator asset and DARD, if either is offered as

Must Run, both are treated as available

• Generator asset and DARD status always kept in synch

‒ ATRR’s status doesn’t impact them

‒ For ATRR, if generator and DARD are:

‒ Unavailable, ATRR also unavailable

‒ Must Run, ATRR can be either Must Run or Unavailable

‒ Participant must call ISO control room to change

status in real time (see preceding slide)

50

Status Interplay

DAY AHEAD REAL-TIME OPERATIONS

GEN DARD GEN DARD ATRR

or

or

or

= Must Run = Unavailable

ISO-NE PUBLIC

Key to eMarket Fields

51

MyFacility_GEN

25.0

PINK FIELDS indicate data have not been saved yet or are unacceptable (if accompanied by error message)

WHITE FIELDS can be changed by participant

DOTTED FIELDS represent redacted info for examples

DARK FIELDS cannot be changed

ISO-NE PUBLIC

Manage Availability and Offers or Bids Separately for Each CSF Asset TypeLook for Appropriate Tab

52

Remember, participant is responsible for developing day-ahead bids and offers so that CSF does not get day-ahead obligation to charge and discharge at same time. ISO day-ahead software will not check for this.

!

Use to manage generator asset1 Use to manage dispatchable asset-

related demand (DARD) asset2 Use to manage alternative technology

regulation resource (ATRR) asset

3

ISO-NE PUBLIC

Portfolio Manager TabsStart by Adding Each CSF Asset into Corresponding Portfolios

53

Add MyFacility_GENto generationportfolio

1

My_CSF_GEN MyFacility_GEN

Add MyFacility_ARDto asset-related demand portfolio

2

My_CSF_ARD MyFacility_ARD

Add MyFacility_ATRRto regulationportfolio

3

My_CSF_ATRR MyFacility_ATRR


Questions?

54

Coming Up: eMarket Requirements for CSF Generator Assets Examples Settlement and Billing Impacts Additional Resources

ISO-NE PUBLIC

CSF Generator AsseteMarket Rules for Continuous Storage Facilities

55

ISO-NE PUBLIC

Generation Tab: Unit Default ParametersInputs Here Establish Default Values

56

MyFacility_GEN

MyFacility_GEN (12345) on 29-Dec-2018

MyFacility_GEN

12345

CSF generator asset must be selected1

Denotes a CSF (as would “ESD”)2

Unchangeable—CSFs ineligible for offline reserves (“UD” = undefined)

3

Regulation only available with ATRR asset

4

Must be set to Must Run, unless unavailable

5

My_CSF_GEN

100.0

ISO-NE PUBLIC

57

Generation Tab: Schedule Detail DefaultsInputs Here Establish Default Values

1A Max Daily Energy value is the maximum amount of energy a unit can produce in one operating day, whereas a blank field means the value is unlimited. Specifying a value allows you to choose to operate as a limited-energy generator (LEG) in real time.

MyFacility_GEN

MyFacility_GEN (12345) – DFLPRICE (1234501 Price-based) on 31-Dec-2018

Intertemporal parameters must be set to zero

2

Specify value to indicate limited energy in day-ahead market and enable hourly LEG limits1

1

Economic Min and Emergency Min must be set to zero3

My_CSF_GEN

ISO-NE PUBLIC

Limited Energy Generator (LEG) Option

• Enter Maximum Daily Energy value (MWh) in Schedule Detail Defaults tab

• Day ahead, software schedules limited energy in hours with greatest

positive difference between locational marginal price and generator offer

• In real time, two options:

1. Do nothing and operate as economic resource

• Unit dispatched without consideration of Max Daily Energy value (e.g., energy may be

depleted before day’s end)

• ISO may posture resource to preserve capacity through peak hour, if necessary

2. Call ISO control room to activate LEG dispatch

• Unit dispatched economically between CSF’s Eco Min of 0 MW and hourly LEG limit

‒ Participant can call in hourly LEG limit in advance (including 0 MW)

58

ISO-NE PUBLIC

Effective Economic Max

• Participant can offer economic max in eMarket using daily default with hourly overrides

‒ Illustrated on Schedule Detail Defaults screenshot

• But effective economic max may be different from offered economic max to comply with

reliability requirement

‒ Reserves must be sustainable for at least one hour

• Effective economic max is calculated in real time using telemetered available energy

59

ISO-NE PUBLIC

Generation Tab: Hourly UpdatesEconomic Max and Availability for CSF Generator Asset Can Be Set On an Hourly Basis to Override Default Values

60

MyFacility_GEN

MyFacility_GEN (12345) on 25-Jan-2019

MyFacility_GEN (12345) on 25-Jan-2019

My_CSF_GEN

Remember that Economic Min and Emergency Min must be set to zero

ISO-NE PUBLIC

Generation Tab: Schedule Offers Default

61

MyFacility_GEN


My_CSF_GEN

Start Up and No Load Costs must be set to zero

ISO-NE PUBLIC

Generation Tab: Schedule Offer Hourly UpdatesOffers Can Be Set on an Hourly Basis to Override Default Values

62

Schedule Offers Hourly Updates

MyFacility_GEN


My_CSF_GEN

Start Up and No Load Costs must be set to zero

ISO-NE PUBLIC

Generation Tab: Generation by PortfolioPortfolio Clearing Results in Day-ahead Energy Market Based on Economics and CSF Generator Asset Availability

63

My_CSF_GEN

MyFacility_GEN on 25-Jan-2019

MyFacility_GEN


Questions?

64

Coming Up: eMarket Requirements for CSF DARDs and CSF ATRRs Examples Settlement and Billing Impacts Additional Resources

ISO-NE PUBLIC

CSF DARD AsseteMarket Rules for Continuous Storage Facilities

65

ISO-NE PUBLIC

ARD Tab: ARD Default ParametersInputs Here Establish Default Values

66

MyFacility_ARD

MyFacility_ARD (12345) on 29-Dec-2018

12345

MyFacility_ARD

CSF_ARD

CSF DARD asset must be selected

1

Must be set to Must Run, unless unavailable

2

My_CSF_ARD

100.0

Unchangeable—CSFs ineligible for offline reserves (“UD” = undefined)

3

ISO-NE PUBLIC

ARD Tab: Schedule Detail DefaultsInputs Here Establish Default Values

67

MyFacility_ARD

MyFacility_ARD (12345) – DFLPRICE (1234501 Price-based) on 29-Dec-2018

Specify maximum energy to be consumed in day-ahead market

1

Must be set to zero

2

My_CSF_ARD

ISO-NE PUBLIC

Effective Consumption MaxSimilar to Effective Economic Max Discussed Previously for CSF Generator Asset

• Participant can offer max consumption in eMarket using daily default with hourly overrides

‒ Illustrated on Schedule Detail Defaults screenshot

• But effective max consumption may differ from offered max consumption to ensure

sustainability for ≥15 minutes

‒ Necessary to comply with economic dispatch period

• Effective max consumption is calculated in real time using participant’s telemetered

available storage

68

ISO-NE PUBLIC

ARD Tab: Hourly UpdatesMax Consumption and Availability for CSF DARD Can Be Set on an Hourly Basis to Override Default Values

69

MyFacility_ARD (12345) on 25-Jan-2019

My_CSF_ARD

MyFacility_ARD (12345) on 25-Jan-2019

Remember that Min Consumption must be set to zero

MyFacility_ARD

ISO-NE PUBLIC

ARD Tab: ARD by PortfolioClearing Results in Day-Ahead Energy Market Based on Economics and DARD Availability

70

My_CSF_ARD

MyFacility_ARD on 25-Jan-2019

MyFacility_ARD


Questions?

71

Coming Up: eMarket Requirements for CSF ATRRs Examples Settlement and Billing Impacts Additional Resources

ISO-NE PUBLIC

CSF ATRR AsseteMarket Rules for Continuous Storage Facilities

72

ISO-NE PUBLIC

Regulation Tab: Regulation OffersUse to Set CSF ATRR’s Daily Availability and Regulation Limits

73

My_CSF_ATRR

My_CSF on 26-Jan-2019

Reg High and Reg Low values specify offered regulation range1 Sets operating-day

availability2

CSF_ATRR

ISO-NE PUBLIC

Regulation Tab: Regulation Hourly UpdatesUse to Set CSF ATRR’s Hourly Overrides for Availability and Regulation Limits

74

MyFacility_ATRR (12345) on 26-Jan-2019

MyFacility_ATRR (12345) on 26-Jan-2019

My_CSF_ATRR

Reg High and Reg Low values specify offered regulation range1 Sets hourly

availability2

CSF_ATRR

MyFacility_ATRR

ISO-NE PUBLIC

• ATRR’s average net consumption of

0 MW allows ISO to dispatch CSF

generator or DARD asset for energy

while ATRR simultaneously

provides regulation

• To accomplish this:

‒ Regulation range (i.e., Reg High and Reg Low) must be

symmetrical or biased slightly to charging

‒ System validation ensures range doesn’t exceed

maximum or minimum mid-point limit

• Limit will be made available

New Mid-Point Limit Validation RuleOnly Applies to CSF ATRR

75

10.0 −10.0ESD1

Rule applies to both daily and hourly regulation limits

My_CSF_ATRR

My_CSF on 30-Dec-2018

CSF_ATRR

ISO-NE PUBLIC

76

Error Example: Exceeding MAX Midpoint LimitError Must Be Cleared to Submit Offer

If Reg Limit Mid-Point > Max Reg Mid-Point = ERROR

1. Mid-point of regulation range = (Reg High + Reg Low) ÷ 2 = (10 + −8) ÷ 2 = 1.0

2. Reg Limit Mid-Point = mid-point of regulation range ÷ the greater of the absolute value of Reg High and

the absolute value of Reg Low = 1 ÷ 10 = 0.1

3. Max Reg Limit Mid-Point for this unit (set by ISO) = 0.0

4. 0.1 > 0.0 = ERROR

CSF_ATRR

ESD_ATRR Reg Limit Mid-Point Per-Unit [0.1] cannot be greater than the ISO set value for MAX Reg Mid-Point Per-Unit [0.0]. Offered limits are: Reg Low [−8] Reg High [10]

My_CSF_ATRR

My_CSF on 30-Dec-2018

10.0 −8.0

ISO-NE PUBLIC

77

Error Example: Falling Below MIN Midpoint LimitError Must Be Cleared to Submit Offer

If Reg Limit Mid-Point < Min Reg Mid-Point = ERROR

1. Mid-point of regulation range = (Reg High + Reg Low) ÷ 2 = [10 + −16] ÷ 2 = −3

2. Reg Limit Mid-Point = mid-point of regulation range ÷ greater of the absolute value of Reg High and the

absolute value of Reg Low = −3 ÷ 16 = −0.1875

3. Min Reg Mid-Point for this unit (set by ISO) = −0.15

4. −0.1875 < −0.15 = ERROR

ESD_ATRR Reg Limit Mid-Point Per-Unit [−0.1875] cannot be less than the ISO set value for MIN Reg Mid-Point Per-Unit [−0.15]. Offered limits are: Reg Low [−16] Reg High [10]

My_CSF on 02-Jan-2019

My_CSF_ATRR10.0 −16.0CSF_ATRR

ISO-NE PUBLIC

ExamplesHow Continuous Storage Facilities Could Offer or Bid into Markets

78

ISO-NE PUBLIC

79

Example 1Default Offers Are Used for Day-Ahead Commitment of Generator Asset and DARD

Clearing in Day-Ahead Energy Market

AssetHourly Interval

1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24

LMP ($/MWh) $15 $15 $15 $15 $15 $20 $25 $30 $30 $30 $30 $25 $25 $25 $30 $35 $35 $30 $25 $25 $20 $20 $15 $15

MyFacility_GEN 0 0 0 0 0 0 0 1 1 1 1 0 0 0 2 4 0 0 0 0 0 0 0 0

MyFacility_ARD 2 3 3 1 1 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 1 1

MyFacility_GEN

Economic Max (MW): 12

Max Daily Energy (MWh): 10

MW Price

Incremental Energy Offer: 12 $30

12 MW

MyFacility_ARD

Max Consumption (MW): 12

Max Daily Consumption (MWh): 12

MW Price

Incremental Energy Offer: 12 $15

10 MWh from generator asset and 12 MWh from DARD are committed based on market clearing

2

Participant specifies daily max values; do not have to match

1

ISO-NE PUBLIC

80

Example 2Participant Strategically Offers and Bids Day Ahead with Goal of Alternating Discharging and Consumption

Hourly Updates


1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24

MyFacility_GENMW 0 0 0 0 0 0 0 0 0 0 0 0 12 12 12 12 12 0 0 0 0 0 0 0

Price 100 100 100 100 100 100 100 100 100 100 100 100 −150 −150 -150 -150 -150 100 100 100 100 100 100 100

MyFacility_ARDMW 12 12 12 12 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0

Price 50 50 50 50 50 -150 -150 -150 -150 -150 -150 -150 -150 -150 -150 -150 -150 -150 -150 -150 -150 -150 -150 -150

12 MW

Clearing in Day-Ahead Energy Market

Asset

Hourly Interval

1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24

LMP($/MWh)

$20 $20 $10 $10 $20 $22 $25 $27 $30 $30 $30 $25 $30 $35 $29 $25 $35 $35 $20 $20 $20 $20 $20 $20

MyFacility_GEN MW 0 0 0 0 0 0 0 0 0 0 0 0 12 12 12 12 12 0 0 0 0 0 0 0

MyFacility_ARD MW 12 12 12 12 12 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0

Market clears with 60 MWh spread across each asset’s 5 economic hours 3

MyFacility_GEN

Economic Max (MW): 12

Max Daily Energy (MWh): 60

MyFacility_ARD

Max Consumption (MW): 12

Max Daily Consumption (MWh): 60

Participant staggers low and high offers and bids. (Low generator asset offers signal desire to generate, while low DARD bids signal desire not to consume. Conversely, high generator asset offer signals desire not to generate, while high DARD bid signals desire to consume.)2

Participant sets daily max values so to limit each asset to 12 hours of operation (12 MW x 5 hrs = 60 MWh)

1

ISO-NE PUBLIC

81

Example 3CSF Hopes to Regulate at ±10 MW and Generate at 2 MW

Offers and Bids


1 2

MyFacility_GEN

MW 12 12

Price −150 −150

MyFacility_ARD

MW 12 12

Price −150 −150

MyFacility_ATRR

Reg High 10 10

Reg Low −10 −10

Price 0 20

12 MW

Clearing in Real-Time Energy Market

Asset

Hourly Interval

1 2

LMP ($/MWh) $20 $20

MyFacility_GEN MW 2 12

MyFacility_ARD MW 0 0

MyFacility_ATRR MW ±10 0

Generator asset and ATRR selected. CSF receives single dispatch signal between 12 MW and −8 MW in hour 1

4 Only generator asset selected. Single dispatch signal = 12 MW for entire hour 2

5

Low generator asset offer signals desire to generate

1

Low DARD bid signals desire not to consume2

Low ATRR offer signals strong desire to regulate

3


Questions?

82

Coming Up: Settlement and Billing Impacts Additional Resources


Settlement and Billing Impacts

83

Sr. Settlement Analyst, Hourly Markets, SettlementsSarthak Pant

ISO-NE PUBLIC

CSF Impacts to Settlements

• No changes to ISO’s overarching settlement design

‒ CSF assets largely compensated same as any generator, DARD, or ATRR

‒ Same day-ahead and real-time net commitment-period compensation (NCPC) cost allocation

(i.e., same as pumped-storage hydro)

• A few adjustments to reflect CSFs:

‒ Enhanced metered quantity for settlement (i.e., energy quantity)

‒ In NCPC rules:

• Existing NCPC logic extended to all electric storage facilities, unless specified

• “DARD pump” term replaced by “storage DARD”

‒ “Binary storage DARD” specified where applicable

‒ In settlement reports, CSF DARD type identified as “energy storage”

• For details, see Enhanced Storage Participation Revisions filing

84


ISO-NE PUBLIC

High-Level Overview of Continuous Storage Facility Settlement Impacts

85

Includes All Changes Effective April 2019 with Enhanced Storage Participation Revisions

Settlement Type Calculation Impact Settlement Report Changes(No New Reports)

Day-Ahead Energy None None

Day-Ahead NCPCAlways-committed CSF generator asset treated like fast-start unit

New CSF DARD type identified as “Energy Storage”

Energy Quantity New calculation method for CSFs New calculation method identified as “Net Adjustment”

Real-Time Energy None New CSF load asset subtype identified as “Energy Storage”

Real-Time NCPC

• CSF generator asset uses DDP instead of actual output, if CSF ATRR is regulating

• CSF generator asset not eligible for real-time NCPC commitment credit or hourly shortfall NCPC credit

• CSF DARD not eligible for hourly shortfall NCPC credit

• New column in SR_RTNCPCGEN5MIN and SR_RTNCPCDARD5MIN reports: Continuous Storage Regulating Flag

• New CSF credit class identified as “ESD”• New reason codes for CSF used in real-time NCPC settlements

Reserve Market None None

Regulation MarketDARD real-time load obligation related to regulation dispatch of ATRR is excluded from cost allocation

New columns in SR_REGSUMMARY report: RT Load Obligation for DARDs, Pool RT Load Obligation for DARDs, Subaccount RT Load Obligation for DARDs

FinancialTransmission Rights

None None

Forward Capacity Market

• Follows current treatment for pumped storage DARD• Excluded from annual peak and peak contribution None


ISO-NE PUBLIC

Inputs to Energy Quantity Calculation for CSF

• New profiling method due to potential use of net metering telemetry

‒ Positive telemetry reported under generator asset

‒ Negative telemetry reported under DARD

• Net metering for revenue quality meter (RQM)

‒ If positive:

• Generator asset reports positive value

• DARD reports 0 value

‒ If negative:

• DARD reports negative value

• Generator asset reports 0 value

86

ISO-NE PUBLIC

Energy Quantity: New CSF Scaling Factor Calculations (in MW)

87

Scaling Factor(hour)

Asset’s Telemetry MW(five-min)

Total Telemetry MW(five-min)

Adjusted Scaling Factor(five-min)

Net Revenue Quality Meter

Net Hourly Average

Telemetry12

Non-Zero Telemetry

Interval Count

Scaling Factor(hour)


ExampleCSF Energy Quantity Determination in Hourly Settlements

88

ISO-NE PUBLIC

1. Calculation of Hourly Scaling Factor

(Net RQM – Net Hourly Average Telemetry)

x (12 ÷ Non-Zero Telemetry Interval Count)

89

Five-Minute Interval

Telemetry MW

Gen DARD Net

1 4 0

2 4 0

3 4 0

4 4 0

5 4 1

6 4 1

7 8 2

8 8 2

9 8 2

10 8 2

11 0 2

12 0 2

Net Hourly Average Telemetry

ISO-NE PUBLIC

1. Calculation of Hourly Scaling Factor, continued



= (4 – ) x (12 ÷ )

90


Telemetry MW

Gen DARD Net

1 4 0

2 4 0

3 4 0

4 4 0

5 4 1

6 4 1

7 8 2

8 8 2

9 8 2

10 8 2

11 0 2

12 0 2

Net Hourly Average Telemetry

Assumption:

Net Revenue Quality Meter (RQM) 4

ISO-NE PUBLIC




= (4 – 3.5) x (12 ÷ )

91


Telemetry MW

Gen DARD Net

1 4 0 4

2 4 0 4

3 4 0 4

4 4 0 4

5 4 1 3

6 4 1 3

7 8 2 6

8 8 2 6

9 8 2 6

10 8 2 6

11 0 2 −2

12 0 2 −2

Net Hourly Average Telemetry 3.5

Assumption:


Calculate Net = Gen − DARD

ISO-NE PUBLIC




= (4 – 3.5) x (12 ÷ 12)

92


Telemetry MW

Gen DARD Net

1 4 0 4

2 4 0 4

3 4 0 4

4 4 0 4

5 4 1 3

6 4 1 3

7 8 2 6

8 8 2 6

9 8 2 6

10 8 2 6

11 0 2 −2

12 0 2 −2


Assumption:



Calculate non-zero telemetry

intervals = 12

ISO-NE PUBLIC




= (4 – 3.5) x (12 ÷ 12)

= 0.5 MW hourly scaling factor

93


Telemetry MW

Gen DARD Net

1 4 0 4

2 4 0 4

3 4 0 4

4 4 0 4

5 4 1 3

6 4 1 3

7 8 2 6

8 8 2 6

9 8 2 6

10 8 2 6

11 0 2 −2

12 0 2 −2


Assumption:



Calculate non-zero telemetry

intervals = 12Carries forward

into step #2

ISO-NE PUBLIC

Scaling factor (+0.5 MW) applied to

first interval:4 + 0.5 = 4.5 MW

2. Calculation of Net Adjusted Energy Quantity

Scaling factor (0.5 MW) added to each five-minute interval

94


Telemetry MW

Gen DARD Net

1 4 0 4

2 4 0 4

3 4 0 4

4 4 0 4

5 4 1 3

6 4 1 3

7 8 2 6

8 8 2 6

9 8 2 6

10 8 2 6

11 0 2 −2

12 0 2 −2


Energy Quantity MW

Net Adj Gen DARD

4.5

ISO-NE PUBLIC

2. Calculation of Net Adjusted Energy Quantity, continued

Scaling factor (0.5 MW) added to each five-minute interval

95


Telemetry MW

Gen DARD Net

1 4 0 4

2 4 0 4

3 4 0 4

4 4 0 4

5 4 1 3

6 4 1 3

7 8 2 6

8 8 2 6

9 8 2 6

10 8 2 6

11 0 2 −2

12 0 2 −2


Energy Quantity MW

Net Adj Gen DARD

4.5

4.5

4.5

4.5

3.5

3.5

6.5

6.5

6.5

6.5

−1.5

−1.5

4

Scaling factor (+0.5 MW) applied to all intervals

Average net adjusted energy quantity will

equal net RQM

ISO-NE PUBLIC

3. Calculation Of Prorated Five-Minute Energy Quantity in Intervals Where One Asset Reports Zero Value

Net adjusted energy quantity value carries over

96

Five-MinuteInterval

Telemetry MW

Gen DARD Net

1 4 0 4

2 4 0 4

3 4 0 4

4 4 0 4

5 4 1 3

6 4 1 3

7 8 2 6

8 8 2 6

9 8 2 6

10 8 2 6

11 0 2 −2

12 0 2 −2


Energy Quantity MW

Net Adj Gen DARD

4.5 4.5 0

4.5 4.5 0

4.5 4.5 0

4.5 4.5 0

3.5

3.5

6.5

6.5

6.5

6.5

−1.5

−1.5

4

Generator asset reflects positive value

and DARD is 0

A

ISO-NE PUBLIC

3. Calculation Of Prorated Five-Minute Energy Quantity in Intervals Where One Asset Reports Zero Value, continued

Net adjusted energy quantity value carries over

97

Five-MinuteInterval

Telemetry MW

Gen DARD Net

1 4 0 4

2 4 0 4

3 4 0 4

4 4 0 4

5 4 1 3

6 4 1 3

7 8 2 6

8 8 2 6

9 8 2 6

10 8 2 6

11 0 2 −2

12 0 2 −2


Energy Quantity MW

Net Adj Gen DARD

4.5 4.5 0

4.5 4.5 0

4.5 4.5 0

4.5 4.5 0

3.5

3.5

6.5

6.5

6.5

6.5

−1.5 0 −1.5

−1.5 0 −1.5

4

Generator asset reflects positive value

and DARD is 0

A

DARD reflects negative value and generator asset is 0

B

ISO-NE PUBLIC

4. Calculation of Prorated Five-Minute Energy Quantity in Intervals Where Both Assets Report Non-Zero Value

Adjusted scaling factor applied to telemetry values

98


Telemetry MW

Gen DARD Net

1 4 0 4

2 4 0 4

3 4 0 4

4 4 0 4

5 4 1 3

6 4 1 3

7 8 2 6

8 8 2 6

9 8 2 6

10 8 2 6

11 0 2 −2

12 0 2 −2


Energy Quantity MW

Net Adj Gen DARD

4.5 4.5 0

4.5 4.5 0

4.5 4.5 0

4.5 4.5 0

3.5

3.5

6.5

6.5

6.5

6.5

−1.5 0 −1.5

−1.5 0 −1.5

4

Calculate Gen adjusted scaling factor

= Scaling Factor(hour) x (Asset’s Telemetry MW(five-min)

÷ Total Telemetry MW(five-min))

= 0.5 x (4 ÷ [4 + 1]) = 0.5 x (4 ÷ 5) = 0.4

A

ISO-NE PUBLIC

4. Calculation of Prorated Five-Minute Energy Quantity in Intervals Where Both Assets Report Non-Zero Value, continued


99


Telemetry MW

Gen DARD Net

1 4 0 4

2 4 0 4

3 4 0 4

4 4 0 4

5 4 1 3

6 4 1 3

7 8 2 6

8 8 2 6

9 8 2 6

10 8 2 6

11 0 2 −2

12 0 2 −2


Energy Quantity MW

Net Adj Gen DARD

4.5 4.5 0

4.5 4.5 0

4.5 4.5 0

4.5 4.5 0

3.5 4.4

3.5

6.5

6.5

6.5

6.5

−1.5 0 −1.5

−1.5 0 −1.5

4

Calculate Gen adjusted scaling factor= Scaling Factor(hour) x (Asset’s Telemetry MW(five-min)


= 0.5 x (4 ÷ [4 + 1]) = 0.5 x (4 ÷ 5) = 0.4

A

Calculate Gen energy quantity MW= Adjusted Scaling Factor(five-min)

+ Gen Telemetry MW

= 0.4 + 4 = 4.4

B

ISO-NE PUBLIC



100


Telemetry MW

Gen DARD Net

1 4 0 4

2 4 0 4

3 4 0 4

4 4 0 4

5 4 1 3

6 4 1 3

7 8 2 6

8 8 2 6

9 8 2 6

10 8 2 6

11 0 2 −2

12 0 2 −2


Energy Quantity MW

Net Adj Gen DARD

4.5 4.5 0

4.5 4.5 0

4.5 4.5 0

4.5 4.5 0

3.5 4.4

3.5

6.5

6.5

6.5

6.5

−1.5 0 −1.5

−1.5 0 −1.5

4



= 0.5 x (4 ÷ [4 + 1]) = 0.5 x (4 ÷ 5) = 0.4

A


+ Gen Telemetry MW

= 0.4 + 4 = 4.4

B

Calculate DARD adjusted scaling factor= Scaling Factor(hour) x (Asset’s Telemetry MW(five-min)


= 0.5 x (1 ÷ [4 + 1]) = 0.5 x (1 ÷ 5) = 0.1

C

ISO-NE PUBLIC



101


Telemetry MW

Gen DARD Net

1 4 0 4

2 4 0 4

3 4 0 4

4 4 0 4

5 4 1 3

6 4 1 3

7 8 2 6

8 8 2 6

9 8 2 6

10 8 2 6

11 0 2 −2

12 0 2 −2




= 0.5 x (1 ÷ [4 + 1]) = 0.5 x 1 ÷ 5 = 0.1

C

Energy Quantity MW

Net Adj Gen DARD

4.5 4.5 0

4.5 4.5 0

4.5 4.5 0

4.5 4.5 0

3.5 4.4 −0.9

3.5

6.5

6.5

6.5

6.5

−1.5 0 −1.5

−1.5 0 −1.5

4



= 0.5 x (4 ÷ [4 + 1]) = 0.5 x (4 ÷ 5) = 0.4

A


+ Gen Telemetry MW

= 0.4 + 4 = 4.4

B

Calculate DARD energy quantity MW= Adjusted Scaling Factor(five-min)

− DARD Telemetry MW

= 0.1 – 1 = −0.9

D

ISO-NE PUBLIC


Telemetry MW

Gen DARD Net

1 4 0 4

2 4 0 4

3 4 0 4

4 4 0 4

5 4 1 3

6 4 1 3

7 8 2 6

8 8 2 6

9 8 2 6

10 8 2 6

11 0 2 −2

12 0 2 −2




102

Energy Quantity MW

Net Adj Gen DARD

4.5 4.5 0

4.5 4.5 0

4.5 4.5 0

4.5 4.5 0

3.5 4.4 −0.9

3.5 4.4 −0.9

6.5 8.4 −1.9

6.5 8.4 −1.9

6.5 8.4 −1.9

6.5 8.4 −1.9

−1.5 0 −1.5

−1.5 0 −1.5

4 5.03 −1.03 Repeat A–D for remaining intervalsE

Calculate DARD energy quantity MW= Adjusted Scaling Factor(five-min)

− DARD Telemetry MW

= 0.1 – 1 = −0.9

D



= 0.5 x (1 ÷ [4 + 1]) = 0.5 x 1 ÷ 5 = 0.1

C



= 0.5 x (4 ÷ [4 + 1]) = 0.5 x (4 ÷ 5) = 0.4

A


+ Gen Telemetry MW

= 0.4 + 4 = 4.4

B

ISO-NE PUBLIC

103

Calculated CSF Energy Quantity Values Can Be Found in Settlements Report

Trading Interval Hour End Asset Name Asset Type Calculation Method Telemetry Value Energy Quantity

Interval Begin Hour End MW MW

00:00 1 MyFacility_GEN GENERATOR NET ADJUSTMENT 4 4.5










00:50 1 MyFacility_GEN GENERATOR NET ADJUSTMENT 0 0

00:55 1 MyFacility_GEN GENERATOR NET ADJUSTMENT 0 0

00:00 1 MyFacility_ARD ASSET RELATED DEMAND NET ADJUSTMENT 0 0




00:20 1 MyFacility_ARD ASSET RELATED DEMAND NET ADJUSTMENT 1 −0.9








Real-Time Asset 5 Minute Energy Quantity*

Look for them under “Energy

Quantity”

Values used as inputs for other

settlement calculations

*For illustration only; actual report includes other data not shown here

ISO-NE PUBLIC

• No changes to billing process or

billable line-item descriptions

• If new to ISO New England, see billing resources:

‒ Understanding the Bill webpage

‒ Billing Process Summary—brief introduction to billing

process for new customers and guide to available

settlement-related resources

CSF Registration Does Not Impact Billing

104

https://www.iso-ne.com/markets-operations/settlements/understand-bill/

https://www.iso-ne.com/static-assets/documents/2015/01/billing_process_final_123114.pdf


Questions?

105

Coming Up: Additional Resources


Additional Resources

106

ISO-NE PUBLIC

Learn More at iso-ne.com

• Continuous storage facility information

‒ Energy Storage Device (ESD) Project Customer Readiness Webpage

‒ March 7, 2019, Quarterly Settlements Forum

• General market participation

‒ Flowchart of Energy Storage Registration Options (see appendix)

‒ Energy Storage Market Participation Overview Webinar (recording; slides)

‒ New Capacity Qualification for Energy Storage Resources Webinar (recording; slides)

‒ WEM 101: Introduction to Wholesale Electricity Markets (see Upcoming Courses webpage)

‒ Regulation Market

• Regulation Market Settlements: Calculations and Examples

‒ Understanding the Bill: Information to help reconcile billing statements, including

detailed guidance on billable line items and report samples

• Staying informed

‒ ISO Training mailing list: announcements of upcoming learning opportunities

‒ Upcoming Courses: list of scheduled webinars and classroom trainings

‒ ISO Training Materials: recordings and slides of past trainings

‒ ISO Quarterly Settlements Forum (March, June, September, December)

107


https://www.iso-ne.com/event-details?eventId=138265

https://www.iso-ne.com/static-assets/documents/2017/04/20170411-webinar-energy-storage.htm

https://www.iso-ne.com/static-assets/documents/2017/04/20170411-webinar-energy-storage.pdf

https://www.iso-ne.com/static-assets/documents/2019/02/redirect_cms-fcm-new-capacity-qualification-energy-storage.htm

https://www.iso-ne.com/static-assets/documents/2019/02/fcm-new-capacity-qualification-energy-storage.pdf

https://www.iso-ne.com/participate/training/upcoming-courses/

http://www.iso-ne.com/static-assets/documents/2015/01/reg_mkt_01_19_2015.htm

https://www.iso-ne.com/static-assets/documents/2015/02/regulation_market_settlements_02_19_2015.pdf

https://www.iso-ne.com/markets-operations/settlements/understand-bill/

mailto:[email protected]?subject=subscribe

https://www.iso-ne.com/participate/training/upcoming-courses/

https://www.iso-ne.com/participate/training/materials

https://www.iso-ne.com/markets-operations/settlements/quarterly-forum/

ISO-NE PUBLIC

Summary

Today’s training covered:

• The continuous storage facility option for participation in New England’s

wholesale electricity markets

• How to register as a continuous storage facility

• Requirements for managing CSF assets in eMarket software platform

• Examples of how CSF may offer or bid in to markets

• Related settlement changes

• Where to find information on alternative options that storage facilities have for

market participation

• Where to find other helpful resources

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ISO-NE PUBLIC

Ask ISO (preferred)

• Self-service interface for submitting inquiries

• Recommended browsers are Google Chrome and Mozilla Firefox

• For more information, see the Ask ISO User Guide

*Recorded/monitored conversations

Other Methods of Contacting Customer Support

Method Contact Information Availability

Email [email protected] Anytime

Phone*(413) 540-4220(833)248-4220

Monday through Friday8:00 a.m. to 5:00 p.m. (EST)

Pager(emergency inquiries)

(877) 226-4814Outside of regular

business hours

Customer Support Information

109109


https://www.iso-ne.com/static-assets/documents/support/user_guides/ask_iso_user_guide_external.pdf

mailto:[email protected]


Evaluations

110


Appendix

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ISO-NE PUBLIC

Must register as three assets: modeled dispatchable generator asset, DARD, and ATRR

Flowchart of Energy Storage Registration Options

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Required Registration Types

Continuous storage facility

Market Products

Regulation

Energy, reserves, capacity

Energy, reserves, regulation, capacity

Energy, capacity

YES

NO

YES

NO

Will facility offer

regulation service?

Is facility ≥5 MW?

≥5 MW generator centrally dispatched by ISO control room and monitored in real time

<5 MW generator notcentrally dispatched by ISO control room and notmonitored in real time

Receives energy-neutral dispatch signal

Modeled generator

Settlement-only

generator

ATRR

Will facility offer

energy, reserves, & regulation?

YES

NO

Dual registration allowed

Continuous Storage Facility ParticipationPart of the Enhanced Storage Participation Revisions and...

Documents

Transcript of Continuous Storage Facility ParticipationPart of the Enhanced Storage Participation Revisions and...